WO2012154437A1 - Non-aqueous drilling additive useful to produce a flat temperature-rheology profile - Google Patents

Non-aqueous drilling additive useful to produce a flat temperature-rheology profile Download PDF

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Publication number
WO2012154437A1
WO2012154437A1 PCT/US2012/035819 US2012035819W WO2012154437A1 WO 2012154437 A1 WO2012154437 A1 WO 2012154437A1 US 2012035819 W US2012035819 W US 2012035819W WO 2012154437 A1 WO2012154437 A1 WO 2012154437A1
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WO
WIPO (PCT)
Prior art keywords
acid
drilling fluid
mono
polyamine
group
Prior art date
Application number
PCT/US2012/035819
Other languages
English (en)
French (fr)
Inventor
David Dino
Yanhui Chen
Original Assignee
Elementis Specialties, Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Elementis Specialties, Inc. filed Critical Elementis Specialties, Inc.
Priority to BR112013025994A priority Critical patent/BR112013025994A2/pt
Priority to EP12782013.2A priority patent/EP2707450A4/en
Priority to CN201280017597.XA priority patent/CN103492523A/zh
Priority to MX2013011027A priority patent/MX2013011027A/es
Priority to RU2013146703/03A priority patent/RU2013146703A/ru
Priority to CA2830996A priority patent/CA2830996A1/en
Publication of WO2012154437A1 publication Critical patent/WO2012154437A1/en

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
    • C09K8/34—Organic liquids
    • C—CHEMISTRY; METALLURGY
    • C08—ORGANIC MACROMOLECULAR COMPOUNDS; THEIR PREPARATION OR CHEMICAL WORKING-UP; COMPOSITIONS BASED THEREON
    • C08G—MACROMOLECULAR COMPOUNDS OBTAINED OTHERWISE THAN BY REACTIONS ONLY INVOLVING UNSATURATED CARBON-TO-CARBON BONDS
    • C08G69/00—Macromolecular compounds obtained by reactions forming a carboxylic amide link in the main chain of the macromolecule
    • C08G69/02—Polyamides derived from amino-carboxylic acids or from polyamines and polycarboxylic acids
    • C08G69/26—Polyamides derived from amino-carboxylic acids or from polyamines and polycarboxylic acids derived from polyamines and polycarboxylic acids
    • C08G69/34—Polyamides derived from amino-carboxylic acids or from polyamines and polycarboxylic acids derived from polyamines and polycarboxylic acids using polymerised unsaturated fatty acids

Definitions

  • the drilling fluid additive consists essentially of a reaction product of (i) a poly-carboxylic acid having a carboxylic moiety of two or more, (ii) a polyamine having an amine functionality of two or more, and (iii) one or more carboxylic acids with a single carboxylic moiety (e.g., mono- carboxylic acids).
  • Exemplary mixtures of carboxylic acids include: oleic acid/decanoic acid; dodecanoic acid/hexanoic acid; 12- hydroxy-octadecanoic acid/hexanoic acid; and 12-hydroxy-octadecanoic acid/decanoic acid.
  • a process for preparing invert emulsion drilling fluids involves using a mixing device to incorporate the individual components making up that fluid.
  • primary and secondary emulsiflers and/or wetting agents are added to the base oil (continuous phase) under moderate agitation.
  • the water phase typically a brine, may be added to the base oil/surfactant mix along with alkalinity control agents and acid gas scavengers.
  • t heological additives as well as fluid loss control materials, weighting agents and corrosion inhibition chemicals may also be included. The agitation may then be continued to ensure dispersion of each ingredient and homogenize the resulting fluidized mixture.
  • water in the form of brine is often used in forming the internal phase of the drilling fluids.
  • water can be defined as an aqueous solution which can contain from about 10 to 350,000 parts-per-million of metal salts such as lithium, sodium, potassium, magnesium, cesium, or calcium salts.
  • metal salts such as lithium, sodium, potassium, magnesium, cesium, or calcium salts.
  • suitable oil/brine ratios may be in the range of about 97:3 to about 50:50. In some embodiments, suitable oil/brine ratios may be in the range of about 90: 10 to about 60:40, or about 80:20 to about 70:30. In some embodiments, the preferred oil/brine ratio may depend upon the particular oil and mud weight. According to some embodiments, the water content of a drilling fluid prepared according to the teachings of the invention may have an aqueous (water) content of about 0 to 50 volume percent.
  • the drilling fluid additive includes an organoclay.
  • organoclays made from at least one of bentonite, hectorite and attapulgite clays are added to the drilling fluid additive.
  • the organoclay is based on bentonite, hectorite or attapulgite exchanged with a quaternary ammonium salt having the following formula:
  • Ri, R2, R.? or R4 are selected from (a) benzyl or methyl groups; (b) linear or branched long chain alky! radicals having 10 to 22 carbon atoms; (c) aralkyl groups such as benzyl and substituted benzyl moieties including fused ring moieties having linear or branched I to 22 carbon atoms in the alkyl portion of the structure; (d) aryl groups such as phenyl and substituted phenyl including fused ring aromatic substituents; (e) beta, gamma unsaturated groups; and (f) hydrogen.
  • the organoclay is based on bentonite, hectorite or attapulgite exchanged with a quaternary ammonium ion including dimethyl bis[hydrogenated tallow] ammonium chloride (“2 2HT”), benzyl dimethyl hydrogenated tallow ammonium chloride (“B2 HT”), trimethyl hydrogenated tallow ammonium chloride (“3 HT”) and methyl benzyl bis[hydrogenated tallow] ammonium chloride (“MB2HT”).
  • MB2HT methyl benzyl bis[hydrogenated tallow] ammonium chloride
  • polymeric rheological additives such as THIXATROL* DW can be added to the drilling fluid.
  • suitable polymeric rheological additives are described in U.S. Patent Application Publication No. 2004/01 10642, which is incorporated by reference herein in its entirety.
  • an emulsifier can also be added to the drilling fluid in order to form a more stable emulsion.
  • the emulsifier may include organic acids, including but not limited to the monocarboxyl alkanoic, alkenoic, or alkynoic fatty acids containing from 3 to 20 carbon atoms, and mixtures thereof. Examples of this group of acids include stearic, oleic, caproic, capric and butyric acids. In some embodiments, adipic acid, a member of the aliphatic dicarboxylic acids, can also be used.
  • suitable surfactants or emulsifiers include fatty acid calcium salts and lecithin. In other embodiments, suitable surfactants or emulsifiers include oxidized tall oil, polyaminated fatty acids, and partial amides of fatty acids.
  • oleophilic amine compounds that may be suitable as emulsifiers are aminoamides derived from preferably long-chain carboxylic acids and polyfunctional, particularly lower, amines of the above-mentioned type.
  • at least one of the amino functions is not bound in amide form, but remains intact as a potentially salt-forming basic amino group.
  • the basic amino groups, where they are formed as secondary or tertiary amino groups may contain hydroxyalkyl substituents and, in particular, lower hydroxyalkyl substituents containing up to five and in some embodiments up to three carbon atoms in addition to the oleophilic part of the molecule.
  • weighting materials are also used to weight the drilling fluid additive to a desired density.
  • the drilling fluid is weighted to a density of about 8 to about 18 pounds per gallon and greater.
  • Suitable weighting materials may include barite, ilmenite, calcium carbonate, iron oxide and lead sulfide. In some embodiments, commercially available barite is used as a weighting material.
  • fluid loss control materials are added to the drilling fluid to control the seepage of drilling fluid into the formation.
  • fluid loss control materials are lignite-based or asphalt-based.
  • Suitable filtrate reducers may include amine treated lignite, gilsonite and/or elastomers such as styrene butadiene.
  • drilling fluids may contain about 0.1 pounds to about 15 pounds of the drilling fluid additive per barrel of fluids. In other embodiments, drilling fluids may contain about 0.1 pounds to about 10 pounds of the drilling fluid additive per barrel of fluids, and in still other embodiments, drilling fluids may contain about 0.1 pounds to about 5 pounds of the drilling fluid additive per-barrel of fluids.
  • additives such as weighting agents, emulsifiers, wetting agents, viscosifiers, fluid loss control agents, and other agents can be used with a composition according to the present invention.
  • additional additives such as weighting agents, emulsifiers, wetting agents, viscosifiers, fluid loss control agents, and other agents can be used with a composition according to the present invention.
  • a number of other additives besides rheological additives regulating viscosity and anti-settling properties can also be used in the drilling fluid so as to obtain desired application properties, such as, for example, anti-settling agents and fluid loss-prevention additives.
  • the drilling fluid additive can be cut or diluted with solvent to vary the pour point or product viscosity.
  • Any suitable solvent or combination of solvents may be used. Suitable solvents may include but are not limited to: diesel, mineral or synthetic oils, block copolymers of EO/PO and/or styrene/isoprene, glycols including polyalkylene glycols, alcohols including polyethoxylated alcohols, polyethoxylated alkyl phenols or polyethoxylated fatty acids, various ethers, ketones, amines, amides, terpenes and esters.
  • a drilling fluid additive may be added to a drilling fluid, in some embodiments, the drilling fluid additive may be added to a drilling fluid in combination with other additives, such as organoclays discussed above.
  • a drilling fluid additive is added to a drilling fluid in an amount of about 0.1 ppb to about 30 ppb. In other embodiments, a drilling fluid additive is added to a drilling fluid in an amount of about 0.1 ppb to about 15.0 ppb. In other embodiments, a drilling fluid additive is added to a drilling fluid in an amount of about 0.25 ppb to about 15.0 ppb. In other embodiments, a drilling fluid additive is added to a drilling fluid in an amount of about 0.1 ppb to about 5 ppb. In other embodiments, a drilling fluid additive is added to a drilling fluid in an amount of about 0.25 ppb to about 5 ppb.
  • the drilling fluid additive and drilling fluid may be characterized by several rheological or hydraulic aspects, i.e., ECD, high shear rate viscosity, low shear rate viscosity, plastic viscosity, regulating property viscosity and yield point, of a drilling fluid.
  • the rheological aspects may be determined using a Fann viscometer as per standard procedures found in API RP 13B-2 "Standard Procedures for Field Testing Oil-based Drilling Fluids". Viscosity readings can be measured at 600 rpm, 300 rpm, 200 rpm, 100 rpm, 6 rpm and 3 rpm.
  • ECD can be determined by: standard hydraulics calculations found in API RP 13D "Rheology and Hydraulics of Oil-well Drilling Fluids.”
  • HSR high shear rate viscosity
  • LSR low shear rate viscosity
  • PV Plastic viscosity
  • Yield Point corresponds to the 300 rpm reading minus plastic viscosity.
  • a substantially constant ECD may include a decrease or increase in ECD over such temperature variation.
  • the increase in ECD may include: up to 0.5%; up to 1 %; up to 2%, up to 3%, up to 4%; up to 5%; up to 10%; up to 20%; up to 30%; and up to 40%.
  • a drilling fluid according to the present invention may have a lower viscosity at 40°F than conventional muds formulated with sufficient organoclay to provide suspension at bottom hole temperatures.
  • drilling fluids according to the present invention may allow the use of a lower pumping power to pump drilling muds through long distances, thereby reducing down-hole pressures. Consequently, in some embodiments, whole mud loss, fracturing and damage of the formation are all minimized.
  • drilling fluids according to the present invention may maintain the suspension characteristics typical of higher levels of organoclays at higher temperatures. Such suspension characteristics may reduce the tendency of the mud to sag.
  • Sag may include the migration of weight material, resulting in a higher density mud at a lower fluid fraction and a lower density mud at a higher fluid fraction.
  • a reduction of sag may be valuable in both deep water drilling as well as conventional (non deep water) drilling.
  • the present invention may be particularly useful in deep water drilling when the mud is cooled in the riser.
  • a mud using a drilling fluid additive according to the present invention will maintain a reduced viscosity increase in the riser when compared to drilling fluids containing conventional rheological additives.
  • Drilling fluids preparations preferably contain between 1/4 and 15 pounds of the inventive mixture per barrel of fluids, more preferred concentration is 1 /4 to 10 pounds-per- barrel and most preferably 1 /4 to 5 pounds-per-barrel.
  • weighting agents weighting agents, emulsifiers, wetting agents, viscosifiers, fluid loss control agents, and other agents can be used with this invention.
  • Example 1 Preparation of A Drilling Additive By A Two-Step Process
  • Step 1 Preparation of IM-1.
  • a C ,-CIX dimer acid was charged and heated until a molten solid was obtained while stiiring at 350 rpm.
  • Diethylenetriamine was added, at a mole ratio of carboxylic acid groups: amine groups ranging from 1 : 1 to 1 :3, and mixed for 5 minutes.
  • the reaction was heated at 200 °C for 6 hours or until the acid number was less than 5 and the amine value was less than 200.
  • the reaction mixture was cooled to 135 °C and then discharged onto a cooling tray to facilitate isolation of a cmde polyamide product and/or purification thereof and further cooling.
  • the polyamide product was labeled IM- 1 .
  • Step 2 Reaction of I M-1 with a mono-carboxylic acid.
  • IM- 1 was combined with at least one mono-carboxylic acid ranging in amount from about 1 5 wt% to 100 wt% of IM- 1 .
  • the resulting mixture was heated at 80 °C for 1 hour or until the acid was consumed as analytically determined by IR
  • step 2 of Example 1 the titled compound was prepared by reacting IM- 1 with 15 wt% Oleic Acid.
  • Example l b Reaction product of IM- 1 with 25 wt% Oleic Acid
  • Example I d Reaction product of IM- 1 with 100 wt% Oleic Acid
  • Example 2b Reaction product of Diethylenetriamine with C j ⁇ -Crx Dimer Acid and 25 wt% Oleic Acid
  • Example 2 Using the procedure of Example 2 the titled compound was prepared by reacting Diethylenetriamine with Ci 6 -C ls Dimer Acid and 25 wt% Oleic Acid.
  • Example 2 Using the procedure of Example 2 the titled compound was prepared by reacting Diethylenetriamine with Cir,-C i 8 Dimer Acid and 50 wt% Oleic Acid.
  • Example 2d Reaction product of Diethylenetriamine with Cu- Cis Dimer Acid and 100 wt% Oleic Acid [0099
  • Example 2e Reaction product of Diethylenetriamine (139.4 moles) With CIC-CIR Dimer Acid; Oleic Acid (8. 17 moles ' ): And Decanoic Acid (205.29 moles)
  • Example 2 100101 1 Using the procedure of Example 2 the titled compound was prepared by reacting Diethylenetriamine ( 139.4 moles) with C ir-Cis Dimer Acid, Oleic Acid (8. 17 moles), and Decanoic Acid (205.29 moles). ,
  • Example 2 Using the procedure of Example 2 the titled compound was prepared by reacting Diethylenetriamine (139.4 moles) with C IG-QS Dimer Acid, Oleic Acid (8. 17 moles), and Butyric Acid (401 .35 moles). ,
  • Example 2g Reaction product of Diethylenetriamine ( 139.4 moles) With Cifi- s Dimer Acid; Oleic Acid (8. 1 7 moles); And Behenic Acid ( 103.83 moles)
  • Example 2 Using the procedure of Example 2 the titled compound was prepared by reacting Diethylenetriamine ( 139.4 moles) with C i6-Cis Dimer Acid, Oleic Acid (8. 17 moles), and Behenic Acid ( 103.83 moles).
  • Example 2h Reaction product of Diethylenetriamine ( 139.4 moles) With Cuj-Gs Dimer Acid; Oleic Acid (8. 1 7 moles); And Behenic Acid ( 103.83 moles)
  • Example 2 Using the procedure of Example 2 the titled compound was prepared by reacting Diethylenetriamine (139.4 moles) with C
  • Drilling fluids containing the polyamide compositions were prepared for evaluation based on Formulation 1 that contained a synthetic I AO as a base oil and was weighted to 14 ppg with an oil: water ratio of 85: 15.
  • the polyamide compositions were evaluated at different loading levels which were dependent upon the efficiency of each polyamide composition in combination with 6 ppb of a dialkyl quat-bentone organoclay ("organoclay").
  • Polyamide compositions 3196-21 , 3196-38, 3196-39, and 3 196-25 were made by reacting the reaction product of diethylene triamine and (C 16/C18)-dicarboxylic acid ("IM- 1 ") with oleic acid respectively in the amount of 15%, 25%, 50% and 100% by weight of IM- 1 .
  • Polyamide compositions 3168-23, 3 168-28, 3168-22 and 3168-27 were made from diethylenetriamine, C 16-C 18 dimer acid and oleic acid in amount respectively 15%, 25%, 50% and 100% by weight of the reaction product of diethylenetriamine with C 16 C 18 Dimer Acid/Oleic acid .

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  • Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Health & Medical Sciences (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Medicinal Chemistry (AREA)
  • Polymers & Plastics (AREA)
  • Lubricants (AREA)
  • Compositions Of Macromolecular Compounds (AREA)
  • Adhesives Or Adhesive Processes (AREA)
  • Polyamides (AREA)
PCT/US2012/035819 2011-05-10 2012-04-30 Non-aqueous drilling additive useful to produce a flat temperature-rheology profile WO2012154437A1 (en)

Priority Applications (6)

Application Number Priority Date Filing Date Title
BR112013025994A BR112013025994A2 (pt) 2011-05-10 2012-04-30 método para proporcionar um perfil reológico, composição, e, fluido de perfuração a base de óleo
EP12782013.2A EP2707450A4 (en) 2011-05-10 2012-04-30 NON-AQUEOUS DRILLING ADDITIVE FOR THE PRODUCTION OF A FLAT TEMPERATURE RHEOLOGY PROFILE
CN201280017597.XA CN103492523A (zh) 2011-05-10 2012-04-30 用于产生平稳的温度-流变学属性的非水性钻井液添加剂
MX2013011027A MX2013011027A (es) 2011-05-10 2012-04-30 Aditivo de perforacion no acuoso util para producir un perfil de reologia de temperatura plana.
RU2013146703/03A RU2013146703A (ru) 2011-05-10 2012-04-30 Неводная присадка для бурения, полезная для создания плоского температурно-реологического профиля
CA2830996A CA2830996A1 (en) 2011-05-10 2012-04-30 Non-aqueous drilling additive useful to produce a flat temperature-rheology profile

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US13/104,286 US20120289437A1 (en) 2011-05-10 2011-05-10 Non-aqueous drilling additive useful to produce a flat temperature-rheology profile
US13/104,286 2011-05-10

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WO2012154437A1 true WO2012154437A1 (en) 2012-11-15

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US (1) US20120289437A1 (zh)
EP (1) EP2707450A4 (zh)
CN (1) CN103492523A (zh)
BR (1) BR112013025994A2 (zh)
CA (1) CA2830996A1 (zh)
MX (1) MX2013011027A (zh)
RU (1) RU2013146703A (zh)
WO (1) WO2012154437A1 (zh)

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CN103666414A (zh) * 2013-12-12 2014-03-26 中国石油集团渤海钻探工程有限公司 矿物油基钻井液用聚酰胺基胺流型调节剂及其制备方法

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US9611422B2 (en) * 2014-05-29 2017-04-04 Baker Hughes Incorporated Methods of obtaining hydrocarbons using suspensions including organic bases
CN104818004B (zh) * 2015-05-20 2018-03-27 中国海洋石油总公司 一种增粘提切剂及其制备方法和用途
CN105199689B (zh) * 2015-10-30 2018-03-23 北京奥凯立科技发展股份有限公司 一种低粘高切油包水钻井液
CN105368416A (zh) * 2015-12-10 2016-03-02 中国石油集团川庆钻探工程有限公司 油基钻井液用改性多聚酸类提切剂及制备方法
US10626314B1 (en) 2016-07-11 2020-04-21 Byk-Chemie, Gmbh Additive for drilling fluids
CN108003850A (zh) * 2016-10-28 2018-05-08 中国石油化工股份有限公司 油基钻井液用聚酰胺类增粘提切剂及其制法与应用
US10676658B2 (en) * 2017-08-15 2020-06-09 Saudi Arabian Oil Company Oil-based drilling fluids for high pressure and high temperature drilling operations
CN109423263B (zh) * 2017-08-30 2021-05-04 中国石油化工股份有限公司 一种胶结型井壁加固剂及制备方法
CN109423261B (zh) * 2017-08-30 2021-06-22 中国石油化工股份有限公司 一种合成基钻井液用流型调节剂的制备方法及流型调节剂
CN107841298A (zh) * 2017-11-06 2018-03-27 中国石油集团川庆钻探工程有限公司 一种钻井液用聚酰胺抑制剂的制备方法
CN107699215A (zh) * 2017-11-06 2018-02-16 中国石油集团川庆钻探工程有限公司 钻井液用聚酰胺抑制剂的制备方法
CN107722261A (zh) * 2017-11-06 2018-02-23 中国石油集团川庆钻探工程有限公司 适用于钻井液的聚酰胺抑制剂的制备方法
US10131622B1 (en) 2018-01-03 2018-11-20 Saudi Arabian Upstream Technology Company N-hydroxyalkylated polyamines, methods of making N-hydroxyalkylated polyamines, and fluids containing an N-hydroxyalkylated polyamine
CN108467483B (zh) * 2018-03-27 2020-05-22 中国石油大学(华东) 共聚物及其应用和油基钻井液稳定剂及其制备方法以及油基钻井液
CN111849435B (zh) 2020-07-15 2021-03-16 中国石油大学(北京) 含有智能温度响应型聚合物的生物柴油基恒流变钻井液

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Cited By (2)

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Publication number Priority date Publication date Assignee Title
CN103666414A (zh) * 2013-12-12 2014-03-26 中国石油集团渤海钻探工程有限公司 矿物油基钻井液用聚酰胺基胺流型调节剂及其制备方法
CN103666414B (zh) * 2013-12-12 2016-05-18 中国石油集团渤海钻探工程有限公司 矿物油基钻井液用聚酰胺基胺流型调节剂及其制备方法

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EP2707450A4 (en) 2014-10-15
US20120289437A1 (en) 2012-11-15
BR112013025994A2 (pt) 2016-12-27
CN103492523A (zh) 2014-01-01
CA2830996A1 (en) 2012-11-15
RU2013146703A (ru) 2015-04-27
MX2013011027A (es) 2013-12-06
EP2707450A1 (en) 2014-03-19

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